ABB Digital Substation - exicon.websiteexicon.website/uploads/editor/Omaintec2017/Presentations/001... · NSD570 . Teleprotection. RTU560. IEC104, DNP3.0. IEC 61850. AFS family

—OMAINTEC 2107, 23 OCTOBER 2017

ABB Digital SubstationDigital Substation, bridging the gap between analogue and digital technologies.Claudio Marchetti, Power Grids, Global Product Manager

—

INTRODUCTION:

• ABB Digital substation are synchronizing technologies for reliable power.

• Bridging the gap between analogue and digital technologies brings unseen.

• Opportunities for modern utilities. Built on the international standard IEC 61850.

• ABB’s world-leading digital substations achieve new heights in reliability.

• Interoperability and real-time performance. We protect investments while stepping up to meet the challenges of tomorrow.

COURSE OBJECTIVES:

• Introduce digital substation concept and its components and benefits.

October 16, 2017 Slide 2

—

• Introduction and context

• Rational for Digital Substation

• Digital Substation Concept

• Digital substations for Transmission and for Distribution applications

• Non-conventional instrument transformers

• Solutions for retrofit

• Monitoring and Diagnostics

• Long term field experience

• Customer values

• Summary


COURSE CONTENT

—Introduction

—Current challenges and changes facing utilities


Aging infrastructureNearly 70% of the transformers in

the US are more than 25 years old.1

Transitioning workforce40% of the workforce at America’s electric and natural gas utilities will be eligible for retirement in the next five years6

ReliabilityThere is increasing pressure to

continually improve reliability and customer satisfaction.

Spending justificationContinued revenue challenges and regulatory inspection will drive Totex focus and cost constraints.

Cyber securityAttacks on critical infrastructure are increasing in terms of regularity and sophistication.

Through 2018, 50% of IoT device manufacturers will not be able to address threats from weak authentication practices.7

Need for improved customer engagement

Customers expectations of “engagement” are changing.

25 billion devices (not counting smartphones, tablets or

computers) will be connected to the IoT by 2020.3

1 Harris Williams & Co. | 2 ARC Advisory Group, November 2014 | 3 Gartner. Predicts 2016: Unexpected Implications Arising From the Internet of Things. December 2015 | 4 IDC FutureScape: Worldwide Utilities 2017 Predictions | 5 IDC Energy IDC FutureScape: Worldwide Digital Transformation 2017 Predictions | 6 APPA | 7 Gartner. Predicts 2016: Unexpected Implications Arising From the Internet of Things. December 2015IDC Innovators 2017

Business model disruptionBy 2020 non-utility players will seize

20% of the energy retail market.

2.5 GW of electricity will be generated by 20% of Fortune 500 companies,

who will wholesale their distributed energy resource excess power through

utility-independent subsidiaries.4

Renewables penetration Global renewables capacity has increased by 8-10% y-o-y since 2010, and the trend will continue with over 150GW added annually (2/3 of all capacity addition).

CostMinimize Optimize

PerformanceExceed Meet or beat

RiskAvoid Manage

$

—Grid of the Future


Supply • Dramatic renewables growth • Increasing intermittency • Greater volatility, less predictability• More feed-in, take-off points(eg, data centers and ev-charging) • Increasing complexity, need for stability On-and off-grid Control • Automation on “local” level

Demand• Continuing electrification of society • Emerging market consumption growth

The world of energy is changing

Control & information flow is key

Wind power

Residential loads

Industrial loads

Rapid rate of change and requires higher velocity of decision making

Microgrids

Solar power

—Utility customers will increasingly have to deal with very dynamic grids


Control RoomField Operations

CenterBoard Room

Time horizon

BusinessprocessesGridDevices Business

strategy

Digitalization is the only answer for the necessary agility and decision-making velocity

Milliseconds Seconds Minutes Hours Days Weeks Months Years

The need for faster decisions and real-time action requires visibility of the entire business

—ABB – uniquely positioned and a pioneering technology leader

1 Flexible Alternating Current Transmission Systems 2 Voltage Source Conversion3 Gas Insulated Switchgear


Stronger

Ultra High Voltage DC and AC

Resilient transformers

Power quality solutions & FACTS1

Interconnectors

Smarter

Digital substations

Grid automation

Sensor-based technologies

Enterprise software solutions

Greener

Eco-efficient Gas Insulated Switchgear

Ultra low loss, amorphous core and biodegradable oil transformers

HVDC Light2 and FACTS for renewable integration

Enabling a smarter stronger greener grid

Continuously breaking records: more power over longer distances (12 GW over 3,000 km)

Digital substation: smart configuration and interoperability, up to 80% less cabling, up to 50% less outages

Transformers: up to 70% less lossesGIS3: up to ~100% less greenhouse gasesFACTS: more capacity in existing lines

—What is a Digital Substation?

—

Digitization Conversion of analog information in any form to digital form with suitable electronic devices so that the information can be processed, stored, and transmitted through digital circuits

Digitalization is the use of digital technologies to change a business model and provide new revenue and value-producing opportunities; moving to a digital business.

ABB Ability™ value proposition – expertiseProviding expertise to our customers conveys clear customer benefit.

Expertise will be the focus of differentiation to position ABB as a high-value provider using a combination of people, products/technology, and digital know-how.

Partnerships will be key

How ABB Ability™ solutions deliver value


What is Digitalization?

—Digital solutions with ABB Ability


Providing an end-to-end solution from the field to the board room

Network Control

Digital Substations

Connected Asset Lifecycle Management

Operations CenterControl RoomField

Energy Portfolio Management

Board Room

Time horizon

ABB Abilityenables the digital transformation of

BusinessprocessesGridDevices Business

strategy

ABB Ability = ABB’s deep expertise + Digitalization + Best in Class Partner capabilities

Milliseconds Seconds Minutes Hours Days Weeks Months Years

—Digital substations

October 16, 2017 Source: Reinhart, Gunther; 2017; Handbuch Industrie 4.0 Slide 12

The power of data analysis

Computerisation Connectivity Transparency Predictability AdaptabilityVisibility

Ind

ustr

y 4.

0 m

atur

ity

leve

lB

usin

ess

valu

e

Industry 3.0 Development roadmapIndustry 4.0

What is happening?“See”

Industry 4.0

Why it is happening?“Understand”

What will happen?“Be prepared”

How to react autonomously?“Self-optimizing”

—Substation evolution


From wired to optical communication

—

Conventional

Digital Substation and IEC 61850


IEC 61850 Station BusIEC 61850 Station BusReplace wiring and legacy protocols between bays by digital communication

Interface to fieldHardwired point to point connections between primary and all secondary equipment

Conventional substations

Thousands of hardwired point-point connections

—

Digital



IEC 61850 Station Bus

SAMU

NCITNCIT

SAMU

NCIT Non-conventional instrument transformers

SAMU Stand-alone merging units

NCITNCIT

SAMUSAMU

IEC 61850 Process Bus

Digital substations with process bus

The process bus reduces cabling and efficiently distributes information

– All signals digital on station and process level

– All information available on communication network analog measurements, switchgear status, monitoring data

– Control and protection commands on highly available fiber optics

– Information is acquired ones and distributed on the bus

—

IEC 61850 communication services



Client-Server

– Reliable point to point sessions for central monitoring and control

– Commands, reporting, logs, file transfer,…

GOOSE

SV,GOOSE

Bay 1

Process bus

Station bus

Merging Unit

Prot & Ctrl Devices

Ethernet Switch

StationComputer

Gateway

Bay n

Client-Server

SAM600SAM600

GOOSE

– Real-time data broadcast for station wide applications e.g. interlocking

– Binary data, indications, commands

Sampled Values (SV)

– Real-time data broadcast for collecting measurements from process

– Sampled analog values

—What is a digital substation?


Substation automation protection and control system with IEC 61850 station bus

IEC 61850 process bus, connecting the switchyard to the protection and control system

Stand-alone merging units, bridging the gap between analog and digital world. Compliant to IEC 61850

Non-conventional instrument transformers increase safety and reduce footprint

Communication system

Advanced system and equipment supervision for efficient asset management

—ABB Digital Substation solutionsPrimary system solutions



Digital technology from end to end

SAM600

Relay room with process bus based protection

UniGear Digital MV switchgear with NCITs

SAM600 to digitize bushing CT measurements

CoreTec transformer monitoring with CoreSense

High Voltage Medium Voltage

Utility communication on MPLS/TP and existing SDH networks with FOX615

Mobile workforce management

Cyber security on substation borders, system level and in the electronic devices

Asset Health Center

FOXMAN NMS

SDM600 Data

manager

Process bus

Station bus

FOCS optical CTs: free-standing or integrated in DCB*

SAM600 process bus IO to bridge the gap between analog and digital

GIS w. NCIT for U&I

Smart local control cubicle with MSM switchgear monitoring

Intelligent substation

HMI

SDM600 Data

managerOperator workplace

Asset and system management

From high voltage to medium voltage, AIS and GIS

Fro

m p

roce

ss t

o n

etw

ork

leve

l

—ABB solutions for digital substations


– Digitization of the signals in the process level

– Communication via IEC 61850

– System-wide engineering via integrated software

– Visualization, system and access control on the field level

– Connection to higher-level network management and asset management solution via MLPS-TP

– Connectivity to Microsoft Azure Cloud

Portfolio and architectureeSecurity & Data

Management SDM600Asset

ManagementNetwork

Control CenterPSGuard

WAMS

Security & DataManagement

SDM600

Computer HMIMicroSCADA

SYS600C

AFR677 Router

SYS600CGateway

AFF66xFirewall

VPN

AFS family Ethernet Switch

Net

wor

k Le

vel

Stat

ion

Leve

lB

ay L

evel

Proc

ess

Leve

l SAM 600Process bus I/O system

FOCS Merging unit

for AIS optical CT

Relion 670/650 Bay control

Relion 670/650 Protection

REB5xx Busbar protection

SAM 600Process bus I/O system

CP-MU Merging unit for GIS NCITs

IEC 61850 / Process bus

Communication networks

System Engineering Software Tools

RTU540

IET600 PCM600

ITT600

System configuration

Deviceconfiguration

SystemTesting

FOX615 Multiplexer

NSD570 Teleprotection

RTU560

IEC104, DNP3.0

IEC 61850



IEC 61850 / Process bus

AIS and GIS Primary switchgear (NCIT)

FOCS CP3,04,14


October 16, 2017 NCIT, Non-Conventional Instrument TransformerSlide 21

Instrument transformers with NCIT (sensors)

Merging Unit

FOCS sensor head and electronics

Combined Current & Voltage sensor

IEC 61850-9-2LE

IEC 61850-9-2LE

—

Smaller and saver GIS substations with reduced maintenance

Targets of digital solutions

October 16, 2017 NCIT, Non-Conventional Instrument TransformerSlide 22

Increased safety through NCITs

– GIS with non-conventional instrument transformers for current and voltage measurement

Optical process bus replaces tons of copper cables

– Smart local control cubicles with IEC 61850 connectivity for smooth integration into substation automation systems

Digital GIS for even more compact substations with high safety and short installation time

Smart primary equipment



ELK-CP NCITs for GIS

– Redundant, combined current and voltage sensors for gas insulated switchgear (Rogowski coils, capacitive dividers)

– Metering, protection and control accuracy in a single device

– World’s first IEC 61850-9-2LE-compliant, UCA-certified merging unit

– Available for transmission level GIS since 1997 (initially with proprietary communication)

NCITs solutions for GIS

CP04

CP14

CP3

NCIT, Non-Conventional Instrument Transformer

—

Smaller and safer AIS substations



Increased safety and higher flexibility through NCITs

– Optical current sensors eliminate the risk of open CT circuits and do not know saturation

More compact substations through combination of various functions in one primary apparatus

– Integration of optical CTs in circuit breakers

– Modular and compact mixed technology systems

Standard compliant connectivity

– IEC 61850 on process level

Digital AIS substations can be more compact, are quicker to install and safer to operate

Smart primary equipment FOCS

FOCS, Fiber Optical Current Sensor


FOCS, Fiber Optical Current SensorOctober 16, 2017 Slide 25

Sensors solutions for HV AIS

NCITs solutions for GIS

Free standing optical CT, FOCS-FS

– Filled with N2 instead of SF6 it is safe and environmentally


Disconnecting circuit breaker (DCB) with FOCS

– Disconnecting circuit breaker with integrated optical CT for maximum space reduction


FOCS sensor and electronics

– Installation of sensor heads on bushings of dead tank breakers, transformers etc.

Redundant

FOCS replaces many CT cores Less foundations

No iron core No saturation and linear

FOCS electronics

FOCS sensor headFOCS-FS

FOCS+DCB



PASS (Plug and Switch System) with Motor DriveTM 1.4

– Digitally controlled motordrive for CB operation

– Drastically reduction of moving party enables highest reliability

– Local control of all switching objects in PASS

– IEC 61850 interface for integration in protection and control system

Modular GIS system with direct IEC 61850 connectivity



Unigear Digital switchgear solution

– Non-conventional current and voltage sensors

– 615 series IEDs exchange GOOSE and IEC 61850-9-2 sampled voltage values on station bus within the switchgear

– IEDs can act as publisher and receiver of sampled values

– Only voltage values are exchanged

Features

– Lower losses due to sensors

– Faster delivery due to flexibility

– Environmentally friendly

– Smaller foot-print (no extra metering cubicle)

– Easier engineering, less hard wiring

– IEC 61850 standard

MV switchgear solution


1 Up to 90% of GIS maintenance is related to SF6October 16, 2017 Slide 28

MSM modular switchgear monitoring

MSM SF6 monitoring allows users to:

– Early detect SF6 leakages and thus minimize SF6 emissions

– Have more time to prepare countermeasures

– Get a detailed report of banked SF6 in the equipment and simplify preparation of SF6 balance sheets

– Reduce inspection work and maintenance cost 1)

Primary equipment monitoring

VisualizationWeb interface

Data collection andvisualizationIEC 61850Substation HMIHistorian database

MSMStack

Localdisplay

Local controlcubicle

Local controlcubicle

MSMStack

Localdisplay

SF6 stage 1 gas warning

SF6 density

SF6 stage 2 gas alarm

$$$

$$

How much time do I have?

Early detection of critical leakage rates

Time



Primary equipment monitoring

– Transformer electronic Control CoreTEC

– Monitoring and diagnostics functions

– Cooling control

– Dissolved gas analysis by CoreSense

– Connectivity of CoreTEC to IEC61850

– Data Analysis in Asset Health Monitoring to optimize operation and maintenance

CoreSense

CoreTEC

CoreTec transformer monitoring

—The ABB offering for digital substationsSecondary system solutions



SAM600 process bus IO system

Bridging the gap between analog and digital technologies

SAM600 modular process bus IO system is placed in the field to connect conventional equipment to IEC 61850 process bus

SAM600-CT

– Current measurement for protection and metering

SAM600-VT

– Voltage measurement for protection and metering

SAM600-TS

– For time synch and more

SAM600-IO

– Scalable IO for binary signals from disconnectors, earthing switches, breakers, transformers…

Modular process IO system for new and retrofit installations

—

Digitizing primary signals made easy

SAM600 – ABB’s process bus IO system


For interfacing primary equipment to IEC 61850 process bus

– Connects to conventional current or voltage transformers

– Provides time synchronization (optional)

– Adapt to different applications types by chanining SAM600 modules into a system

Compact and optimized form factor

– DIN-rail mountable for fast installation and replacement

– Installation in station panel or marshalling kiosks

Termination of primary cabling on SAM600 modules

– Termination of process and auxiliary signals

Modular IO system

SAM600 modules in outdoor cubicle

—

Enabling digital substation solutions

SAM600 series


Easy to use

– The module-per-primary object concept allows for intuitive and flexible system design

Unrivalled flexibility

– SAM600 modules fit to any substation layout (double busbar, 1½ breaker, …)

– Large number of communication ports minimize the need for switches in process bus

Cost saving retrofits

– Modular system enables “non-invasive” retrofit with minimum outage time and step-wise commissioning

Unique modular approach

Benefits

—

Application example – transformer feeder

SAM600 – the digital substation enabler




Relion series protection and control IEDs

650/670 series protection and control IEDs – IEC 61850 process bus for all application

– Support of pure digital as well as mixed applications with digital and conventional IO

– Redundant communication on station and process bus

– Precise time synchronization over Ethernet (IEEE1588/IEC 61850-9-3)

PWC600 Switchsync– Controlled switching with process bus connectivity

REB500 distributed busbar protection – For any station size and layout supports IEC 61850-9-2

process bus

Protection and control for any application

—

Enabling digital substations

Relion® 670 and 650 series


Up to 6 Ethernet ports that can easily be configured for MUs

Typical solutions

– Station bus is with redundancy PRP

– Process bus with redundancy HSR

– Time sync via PTP IEC/IEEE 61850-9-3 (Legacy PPS)

Connectivity to 3rd party IEDs/sensors/MUs using standardized methods:

– Communication: IEC 61850-8-1, IEC/UCA 61850-9-2LE

– Time sync: IEC/IEEE 61850-9-3 (PTP)

– Redundancy: IEC 62439-3 (link redundancy PRP/HSR)

Easily adaptable to most digital substation topologies

Support for various digital substation architectures

Service 670/650

MMS Server

GOOSE Publisher, subscriber

Sampled values

Subscriber

PTP Ordinary,boundary, transparent

IEC 61850 services

—

Enabling digital substations

Relion® 670 and 650 series


With conditional blocking, only dependent functions are blocked instead of everything

Increased availability by providing protection, control, monitoring as much as possible based on quality of inputs

In the example here: with loss of NCIT input from one side of the transformer, only dependent functions are blocked (greyed out) E.g., OC4PTOC.Beh=Blocked

Increased availability, cost effective

Conditional blocking

—

Intelligent station HMIs



Station level systems and HMIs in digital substations gain on importance, fulfilling functions like

– Substation monitoring and control

– Data management

– Cyber security management

– Primary equipment monitoring

– Secondary equipment management

– Providing data to higher level asset health system

The intelligent station HMI provides better data for efficient operation and maintenance

Substation data management



Station level solutions for any station size

MicroSCADA Pro– Monitoring and control of all kinds of substations for

any voltage level. From local and remote.

RTU500 series – Flexible and modular RTU to adopt to a variety of

electrical and process automation applications

SDM600– Substation data manager for service and security data

across substations. E.g. to:• Collect disturbance records

• Consolidate version information

• Manage user accounts and receive security events

Station solutions



See the unseen from a new perspective

The comprehensive software solution for automatic management of service and cyber security relevant data across your substations

– Disturbance recorder handling

– Cyber security management

– Maintenance and service data management

SDM600 sets new marks in ease of configuration and visualization of data

SDM600 System data manager

—System Data Manager SDM600


Independent and automatic

– Automatic upload of disturbance recorder (DR) files from IEDs

– Supported protocols: IEC 61850-8 (MMS), FTP, ABB RTU500 and Windows File System access to integrate legacy protocols

– Polling the IEDs for new files

– Seamless integration into existing substation automation system

– Send DR info and Short Report via email

– Visualization of DR Data

– Export DR files to file system for integration into another system

Management of disturbance recorder data



Manage your users

– System wide user management

– Role based access control (RBAC) according IEC 62351-8

– Enforce password policies

– For Relion 670/650 2.1, Windows PCs, MicroSCADA Pro and any RADIUS capable device.

– In accordance with NERC CIP and BDEW whitepaper requirements

Central user account management



Monitor your system

– Store user activities and other security events from IEDs or system level components

– Integration of any device using Syslog protocol (UDP and TCP)

– Integration of Windows computers (converting Windows Event Logs)

– Categorization of unknown events based on rules

– Built in visualization and reporting

– Integrate SDM600 into an existing event logging system

System wide cyber security event logging



Collect and track service data

– Reading service relevant data from supervised Devices

– Tracking configuration versions from IEC 61850 IEDs, Windows PCs, RTU500 and SNMP devices

– Visualization of changes in the dashboard and dedicated event list

Track service relevant data

—

User interface

System Data Manager SDM600


When did it happen

Whe

re d

id it

hap

pen

DR Event representation

Correlations

User activity and configuration changes

—

Highly available and reliable utility communication



IEC 61850 instead of copper wires for truly digital integration of utility communication equipment

Using the benefits of IEC 61850 to communicate across substations

Move from TDM to packet-switched communication for operational, maintenance and protection data

Utility-grade equipment to ensure the reliable operation of the power grid is required

Technology shifts in utility communication



Utility communication for digital substations

FOX615: fiber optic multiplexer– Hybrid SDH/MPLS-TP multiplexer with integrated

teleprotection functionality and IEC 61850 GOOSE interface

NSD570: teleprotection– Solution for the transmission of protection commands

over all kind of communication media.

– Support for IEC 61850 GOOSE

AFS switch family– IEC61850 Ethernet family including switch, router and

firewall functionality

Utility communication


*) AIS FOCS measurements with 0.1s accuracy class October 16, 2017 Slide 48

Metering with IEC 61850-9-2 process bus

Landis+Gyr E880

– Grid meter with IEC 61850-9-2LE connectivity.

– First installations already back in 2004

– Proven track record on accuracy with ABB NCITs

– (See Cigré paper B3-211, Cigré 2014 von Jakob Widmer, Landis+Gyr)

Prosoft ARIS EM

– Revenue meter capable to handle multiple IEC 61850-9-2LE streams

ABB NCITs provides measurements with 0.2s accuracy class *)

SAM600 provides measurements with accuracy of 0.1%

Revenue meters for digital substations

—Concepts and applicationsDigital substations

—Station and process bus concepts


Fully separated station and process bus

– Fully separated station and process bus enables highest availability, performance and security.

– Mission critical data (e.g. SV and goose for trip) is separated from the bulk data on station bus

– Highest performance on process bus network

– Clear separation of bulk and protection data enables safe and simple maintenance

– Separate security zones

Separate station and process bus

Control Protection

Merging unit

Switchgear control unit

Process busGOOSE, SVPTP

Station HMI Gateway

Station busMMS, GOOSEPTP (SV of BB voltage)

GPS clock

Bay level IEDs acting as PTP boundary clocks

Optional station bus connection for monitoring and health data (MMS)

Critical for protection and control

Critical for control “only”

—Digital substations for greenfield and brownfield


SAM600 process bus IO system

Bridging the gap between analog and digital technologies

SAM600 modular process bus IO system is placed in the field to connect conventional equipment to IEC 61850 process bus

SAM600-CT

– Current measurement for protection and metering

SAM600-VT

– Voltage measurement for protection and metering

SAM600-TS

– For time synch and more

SAM600-IO(release Q4/17)– Scalable IO for binary signals from disconnectors, earthing

switches, breakers, transformers…

Modular process IO system for new and retrofit installations

—Digital AIS substation


Air insulated switchgearStation level:MicroSCADA Pro station HMI and gatewayRTU500 series as Gateway, HMI, data collectionSDM600 Substation data manager

IET600/ITT600/PCM600 on engineering workstation

Protection and control panels:Relion series protection & control IEDs with IEC 61850 station & process bus9-2 revenue meters (e.g. from Landis+Gyr)

SAM600Outdoor panels:SAM600 process bus IO system FOCS opto-electronic modules/merging units FOCS

SAM600

SAM600

Primary equipment:Disconnecting CB with integrated FOCS optical CTFOCS-FS, free-standing optical CT

—Digital GIS substation


Gas insulated switchgear

Protection panels:Relion series protection IEDs with IEC 61850 station & process bus9-2 revenue meters (e.g. from Landis+Gyr)

SAM600

Integrated local control cubicle (LCC):REC650/670 bay control IED and process interfaceMerging units for NCITs and CITs (where required)MSM switchgear monitoring

Station level:MicroSCADA Pro station HMI and gatewayRTU500 series as Gateway, HMI, data collectionSDM600 Substation data manager

IET600/ITT600/PCM600 on engineering workstation

Non-conventional instrument transformer:ELK-CP NCITs for current and voltage

—Digital GIS/AIS substation


Power transformers

Transformer protection and control:RET670 transformer differential protection with 9-2 (and conventional inputs)Tap change control in separate IED or integrated in RET670

Outdoor cubicle:SAM600 stand alone merging units to digitize bushing CT measurementsSAM600-IO for binary data (e.g. tap changer positions and controls)

Station level:MicroSCADA Pro or RTU500 station HMI and gateway, including IEC 61850 data from CoreTecCoreTec Web HMIData connection to Asset Health center

Monitoring equipmentCoreTec with CoreSens and other sensors…

SAM600 SAM600

—Testing and maintenance

—Engineering and testing of digital substations


Conformance certified configuration tools

Interoperable system design using conformance certified engineering tools.

– IET600 system configuration tool and PCM600 IED configuration tool are IEC 61850 Ed.2 conformance certified

Simple and save testing using easy to use software

– IET600 SA Explorer is a easy to use IEC 61850 testing tool for station and process bus

Tools overview

IET600System Engineering

ITT600System Testing

PCM600IED Configuration

—Testing and maintenance

SAMU: Stand-alone merging unit to integrate conventional CTs and VTsBIED: Breaker IED to integrate breakers, disconnectors…October 16, 2017 Slide 57

“Wiring” testDone automatically through self-supervision features of NCITs, MUs and IEDs

Protection and control testing– “Non-conventional” secondary injection

• Simulation of IEC 61850-9-2 LE traffic instead of secondary injection

– Test modes to simulate U/I, by

• NCITs and merging units

– Primary injection

• Stability and directional tests

– Software based isolation of trip circuits

Impact on protection and control testing

NCIT

MU

Protection

Process bus

9-2simulator

Control

Primaryinjection

SAMU

Secondaryinjection

BIED

SW based isolation

—Efficient analysis of digital data


Hardwired signal exchange IEC 61850 GOOSE signal exchange

Testing of binary signals

Testing wire by wire, signal by signal with volt-meter

IEC 61850station bus

Bay level IEDs

Hardwired connections

IEC 61850 process bus

SAM600

GOOSE

Testing of several signals at the same time

Time measurement between status changes

Recording for offline analysis

—Efficient analysis of digital data


Hardwired CT/VT connections IEC 61850 sampled analog values

Testing of analog measurements

Testing requires access to CT and VT circuits

IEC 61850station bus

Bay level IEDs

Hardwired connections

IEC 61850 process bus

SAM600

Sampled values

Collection, display and evaluation of sampled analog values

— Oscilloscope display

— Phasor diagram

— Quality information

— Online and offline analysis

—

IEC61850 Ed2 – Test mode and simulation

Efficient testing without system down time


3. Start injection of simulated values from test set

Testing procedure

Pxxx

LPHD

TCTR

TVTR

Merging Unit

XCBR

Switchgearcontrol

Test equipment

Mod=Test Sim=TRUE

Mod=Test/blocked

SV (Sim=FALSE) SV (Sim=TRUE)

XCBR.Pos.opOkXCBR.Pos.tOpOk

GOOSE (q.test=TRUE)

1. Prepare protection IED and Switchgear controller for testing by setting IEC 61850 “Mod” and “Sim” attribute

• The protection IED shall accept simulated SV and send GOOSE marked as test

• The switchgear controller shall accept GOOSE marked as test but block its trip outputs

2. Connect test set to Ethernet network

4. Protection IED will initiate a trip with q.test=TRUE

5. XCBR will receive GOOSE but not tripXCBR output can be verified through OpOk and tOpOk attributes

—Operation and maintenance


Clear information for operators

For efficient operation and maintenance:

– Permanent system supervision of all intelligent electronic devices.

– From communication gateways to MUs and NCIT electronics

– Supervision diagrams for fast overview of the substation health

– Not requiring expert know-how of operation personnel

System supervision for simple fault finding

—

A fleet-wide analytics platform to improve processes through risk-based optimization

ABB Ability™ Asset Health Center™


Continuous optimization and improvement

All data sources:• Sensors• Historian• Databases• EAM

Advanced operational business intelligence

Enterprise asset and work management

Statistical models(Azure Machine Learning)

Expert models(ABB, third party)



Operation and maintenance efficiency

Asset Health Center, part of ABB Connected Asset Lifecycle ManagementTM leverages ABB’s substantial, industry-leading expertise in electrical equipment manufacturing and service to …

– Consolidate information from a variety of sources

– Determine current condition of electrical assets

– Predict and enables planning based on risk of failure and operational criticality

– Leverages real-time operations data for improved efficiencies

– Provide recommendations for corrective action

– Improves responsiveness by delivering the right work at the right time to the right people

– Prioritize maintenance and replacement across the fleet and aid in creation of Work Requests

Condition instead of time based maintenance

Predictive analytics for efficient asset maintenance and management

—

US transmission owner

Asset Health Center reference


Territory in 11 states5.1 million customers40K miles of electric transmission lines215K miles of electric distribution line

8,846transformers

20,572 breakers

3,384 batteries

Prevented at least one $5M transformer failure in the first year!

18%Transformers over

years old60

33%Transformers over

years old50

—Digital Substation benefits

—

Overview

Benefits of digital substations


– Safety

– Reduced substation footprint

– Interoperability

– Reduces copper cabling

– Ease of configuration

– Maximum reliability and availability

– Real-time performance

– Smart Grid communications capabilities

– Reduces cost of ownership

Digital substations are safer to operate, future proof and require less space

Main benefits

—

Less space in switchyard



Reduction of AIS switchyard footprint by up to 50%— By using circuit breakers with integrated disconnecting

functionality and optical current transformers

— Less material and foundations, reduced installation and engineering effort

— Higher reliability due to less stressed equipment

Reduction of GIS footprint by up to 30%– By using NCITs for current and voltage

– By integrating LCCs to GIS switchgear

High function integration and NCITs enable space reduction in the switchyard

Space requirement reduced by half Conventional substation Digital substation

Disconnector Disconnector

CT

Circuit breaker with integrated optical CT and disconnecting functionUp to

50%reduction

space in the switchyard

Less space required, “One bay one footing” conceptBenefits of digital substations


Disconnector Circuit Breaker DisconnectorConventional current

measurement

Disconnecting circuit breaker

Fiber-optic current sensor

1. Reduce needed space with DCB, Disconnecting Circuit Breaker

2. Minimize the footprint even further with integrated optical CT

DCB+FOCS

—

Less transport



– More than 30 tons material can be saved for an average sized transmission level substation with 7 feeders

– The weight of the fiber optic cabling is around 90% less than the copper cables it replaces

– By using optical instead of conventional CTs almost 80% weight reduction on CTs is achieved

Less transport, less CO2, less heavy lifting equipment required

30 tons less material Conventional substation Digital substation

Around

30tLess material

—

Less copper


October 16, 2017 * in transmission level AIS substationsSlide 71

– By replacing copper cables between switchyard and relay house by fiber optics

– By replacing horizontal wiring between protection and control IEDs with IEC 61850

– By reducing number of connections between primary apparatus and redundant process interfaces modules

– Copper cables remain for power supply and short connections between primary apparatus and marshalling kiosks in the switchyard.

Point to point copper connections get replaced with fiber optics

Reduction in copper cables by up to 80%* Conventional substation Digital substation

Up to

80% copper cable

reduction

—

Less space in relay room



60% and more reduced space for protection and control panels

– The IEDs require less space due to absence of conventional IOs

– Absence of terminals enable integration of more IEDs per panel

– Integration of more functions in IEDs enables further space reduction

High function integration, smaller IEDs and fewer conventional components enables space reduction

Space requirement reduced by half Conventional substation Digital substation

Up to

60% less space in relay room

—

Shorter installation time



40% reduction of installation time for new protection and control systems.

– Fewer panels to install

– Fewer cables to be pulled, connected, tested

– More testing in the factory means less testing on site

Shorter installation time decreases project runtime

Shorter time for secondary system installation Conventional substation Digital substation

40% shorter

installation time of P&C

system

—

Shorter outage time during secondary system retrofits



Reduction of feeder outage time by 40 to 50% during secondary system upgrades

– Full system test from process IO to protection, control and scada system off-site

– Installation of new FO based system while station is in service

– Flexible placement of new protection panels, without depending on SS cabling

Shorter outage times increase system availability and utility revenues

Shorter time for secondary system refurbishment Conventional substation Digital substation

40%outage time

reduction during P&C

retrofit

—

Operational cost reduction



Efficient maintenance

– Supervision of all exchanged data, reduces the need for periodic maintenance testing

– Permanent supervision enables fast and precise actions in case of failures

Fast and save testing

– IEC 61850 testing and simulation features enable fast and save isolation and testing of protection functions

Standard compliance enables efficient future retrofits of secondary system

Lower operational costs thanks to supervision and standards

Savings in maintenance and future retrofitsConventional substation Digital substation

Operational cost

reduction

—

Increased safety



– Handling of current transformer circuits and signaling voltage poses a threat to life and equipment

– Process bus eliminates the galvanic connection between protection and control panels and the switchyard.

– Eliminates CT and VT circuits in the protection & control panels

– Replaces conventional 110/220VDC indications with fiber optics

Eliminates the electrical connection between primary and secondary

Reduced risk of electrical shock

—ABB reference cases

—Laying the foundations of Digital Substations


ABB dedicated to technology leadership

1990 2000 2010 2020

2008ABB installs the first IEC 61850 digital substation pilot

2011ABB installs the first fully operational IEC 61850 digital substation

2014ABB installs the world’s first Asset Health Center for a transmission utility

1996ABB

introduces smart GIS with

NCITs and process bus

2012IEC 61850 Ed.2 is released

2004ABB installs the world’s first IEC 61850 multivendor substation

1992ABB is awarded the first patents for FOCS technology

1996ABB hosts the first meeting to create IEC 61850

2004IEC 61850 is

released2004ABB installs the first FOCS for DC applications

1999ABB installs iPASS digital substations with NCITs and process bus

2017ABB ships 1’000th

UniGear Digital panel

2017More than 1’000 CoreTec are installed on ABB and 3rd party transformers


* Under execution

Highlights,worldwide NL, 2004-2009

GIS NCITL+G revenue meter

Switzerland 2009GIS NCIT,670series, REB500

Sweden, 2010DCB with FOCS,670series

3 more projects in AUare under execution

Australia, 2009GIS NCIT, 3rd NCIT670series

AustraliaGIS NCIT,670series, REB500

AustraliaGIS NCIT,670series, REB500

Australia 2011GIS NCIT,670series, REB500

Switzerland 2011GIS NCIT,670series, 3rd party

Germany, 20123rd party NCIT,REB500

UK, 2014GIS NCIT,670 series

Sweden, 2013AIS 3rd party NCIT,670, 630, 615series

Taiwan, 2014SAM600670series, 3rd party

Taiwan, 2017SAM600670series, 3rd party

India, 2017*SAM600670, 615 series

Brasil, 2017SAM600670series

US, 2016DTB with FOCS, SAM600, 670 series

UK, 2018*SAM600, FOCS670series, 3rd party

CN, 2016 (several)DCB with FOCS3rd party

Laboratory tests

Installations

Poland, 2017*AIS FOCS NCIT,670series

NCITs for gas insulated switchgear

NCITs and process bus - Australia


350 pcs CP-type sensors for current and voltage measurement, installed in 6 substations of Powerlink Queensland in Australia

In continuous operation since more than 15 years (with a proprietary communication system)– Not one of the installed primary sensors has

failed– Experience data predict MTBF of secondary

converters close to 300 years

Real life NCIT experience

Customer: Powerlink Queensland – Australia

Year of commissioning: 1999-2001

Voltage level: 275kV and 325kV

Full substation with NCITs and process bus, Powerlink Queensland / AU

IEC 61850-9-2 process bus and NCITs – Australia CP Sensors for HV GIS


Customer’s need

– Secondary system upgrade of existing 275kV substation with ABB NCITs, protection and control with proprietary process bus

– Future proof, fully IEC 61850 compliant protection and control system with process bus

ABB’s response

– Upgrade to IEC 61850-9-2 compliant system by keeping primary equipment

– Conformance tested CP-MU merging units, Relion 670 series IEDs, REB500, and PWC600 with IEC 61850-9-2 process bus

Customers benefit

– Latest generation, IEC 61850 compliant protection, control and SA system

– Minimum outage times during commissioning

Switchgear with NCITs in service since 1999!

Voltage level 275kV, Year of commissioning 1999, upgrade in 2011 with 9-2

—Summary

—Summary


Industry trend Complete portfolio Less space, safer to operate, reduce OPEX

Technology leadership Improved maintenance planning Main benefits

Digital substations follow the industry trend for better information that enables forward looking decision making

ABB’s digital portfolio ranges from high to medium voltage and process to network level

Digital substations require less space, are safer to operate and enable reduction of operational expenditures

ABB Connected Asset Lifecycle Management enables better maintenance planning and dispatching of maintenance resourcesABB is shaping the digital evolution with first patents

and igniting the creation of today’s most used standard in substation automation

• Safety• Reduced substation footprint• Interoperability• Reduces copper cabling• Ease of configuration• Maximum reliability and

availability• Real-time performance• Smart Grid capabilities• Reduces cost of ownership

Documents

ABB Digital Substation - exicon.websiteexicon.website/uploads/editor/Omaintec2017/Presentations/001... · NSD570 . Teleprotection. RTU560. IEC104, DNP3.0. IEC 61850. AFS family